Well orienting tool and method of use

ABSTRACT

A down hole well tool shown in the form of an orienting tool (OT) has mandrel (16) with helical grooves (16a) thereon and a tubular member (20) which telescopically receives the mandrel (16). Keys (22) on tubular member (22) engage in the grooves (16a). Mandrel (16) is connected with non rotatable coil tubing (T) and member (20) is connected to a bottom hole assembly (BHA) which may comprise a plurality of components or a single device to form a well tool. The orienting or rotating tool (OT) and down hole assembly (BHA) constitute an orienting assembly, for orienting or rotating a device such as a drill bit (13) to drill a deviated well bore, including a horizontal well bore, to a desired target area. Downhole instruments relay to the surface equipment (1) the azimuth, inclination and tool face of the directional drilling equipment.

STATEMENT OF THE PRIOR ART

So far as known to applicant, there are no prior art devices whichenable non-rotatable drill string, such as coiled tubing, to be employedas drill string to drill directional, or deviated well bores, includinghorizontal well bores.

There are various types of directional drilling equipment well known tothose skilled in the art of directional drilling that may be employedwith a conventional rotary drill string formed of tubular membersthreadedly connected together to form the drill string which drillstring is rotated by surface equipment of any well known type to drill adirectional, or deviated well bore including a horizontal well bore.Down hole instruments, such as by way of example only, MWD (MeasuringWhile Drilling), steering tools or gyroscopes, well known to thoseskilled in the art of directional drilling, are used to provideinformation in a form which is relayed to the earth's surface in anysuitable manner, well known by those skilled in the art of directionaldrilling.

This information is interpreted in a manner well known by those skilledthe art of directional drilling to show the direction of the well borebeing drilled by the down hole motor and drill bit on the lower end ofthe drill string and to predict what change in position or orientation,if any, should be made in the down hole directional drilling equipmentto assure that the down hole motor and drill bit on the lower end of thedrill string will drill the well bore to the desired target area.

The orientation of the directional drilling equipment including the downhole motor and drill bit is presently accomplished by rotating the drillstring by any suitable means such as tongs, or the like, at the earth'ssurface when the readings obtained from the instruments employed withthe directional drilling equipment indicate the necessity to rotate thedrill string to re-position the drill string in the well bore forre-orienting the down hole directional drilling equipment, including thedown hole motor and drill bit on the lower end of the drill string so asto face the drill bit and down hole motor in the direction to continuedrilling the well bore to assure that the well bore will hit adesignated or desired target area.

The various types of down hole directional drilling equipment, surfaceand down hole instrumentation, surface equipment and software used todetermine and dictate the orientation necessary for the drilling of adeviated well bore, including a horizontal well bore to a target area,is generally referred to as the steering system or guidance system forthe drill bit.

The use of keys which engage in helical grooves in members in variousdevices is well known.

SUMMARY OF THE INVENTION

So far as known to applicant, it has been considered impossible to use anon-rotatable drill string to drill a deviated or horizontal well boreas there is, so far as known to applicant, no practical, economical wayto D rotate the non-rotatable drill string to orient the down holedirectional drilling equipment and instrumentation including the downhole motor and drill bit to drill the well bore in a desired direction.The present invention allows this to be accomplished in a relativelysimple, inexpensive and quick manner.

The present invention overcomes the problems and obstacles heretoforepresented in connection with employing coil tubing for performingoperations in a well bore, particularly a deviated or horizontal wellbore.

One object of the present invention is to provide a well tool assemblyand method of use for down hole orienting and reorienting of a device ina well bore to accomplish a desired result.

An object of the present invention is to provide a down hole orientingtool for use with a non rotatable drill string to orient a drill bit todrill a well bore in a desired direction.

An object of the present invention is to provide apparatus for rotatinga down hole device by a non-rotatable member.

A further object of the present invention is to provide method andapparatus for drilling a deviated or horizontal well bore to apredetermined target area or location employing coiled tubing as anon-rotatable drill string.

Yet a further object of the present invention is to provide apparatusfor rotating and locking a down hole device in a predetermined, ordesired, rotated relationship or manner by a non-rotatable drill string,which device can be employed for fishing for lost or stuck objects,drilling and other down hole operations in a well bore.

A still further object is to provide apparatus and method for down holerotation and locking of a down hole motor and drill bit in one or moresequential desired rotated or oriented positions as may be necessary todrill a well bore in a desired direction.

A further object is to provide apparatus and method for down holerotation of a down hole motor and drill bit to a desired position todrill a well bore in a desired direction and manner by a non-rotatabledrill string with which they are connected..

An object is to provide apparatus and method for down hole rotation of abottom hole assembly to a desired position relative to a non-rotatablewell string with which the bottom hole assembly is connected.

An object is to provide apparatus and method for down hole rotation of abottom hole assembly or device, locking the down hole assembly or devicein such desired rotated position and reorienting the well tool assemblyor device and relocking it in the reoriented position.

Another object of the invention is to substantially reduce the expensesinvolved in well bore operations by reducing the number of people, timeand equipment employed in well bore operations.

Other objects and advantages of the present invention will become morereadily apparent from a consideration of the following description anddrawings.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a schematic illustration of a well bore with coiled tubingextending therein and one form of a bottom hole assembly with which thepresent invention may be employed;

FIG. 2 is a sectional view of one form of the present inventionillustrating it in its extended or open position and unlocked;

FIG. 3 is a sectional view similar to that of FIG. 2 but showing thepresent invention in a substantially closed or telescoped relationshipand locked;

FIGS. 4A, 4B and 4C are continuation sectional views of another form ofthe present invention in closed or fully telescoped and unlockedposition;

FIGS. 5A, 5B and 5C are continuation sectional views showing yet anotherembodiment of the present invention in closed or fully telescoped andunlocked position;

FIGS. 6A, 6B, 6C are continuation sectional views illustrating the formof the invention shown in FIGS. 5A-5C inclusive when it is in partiallyopen and in unlocked position;

FIGS. 7A and 7B are continuation sectional views showing the form of thethe invention in FIGS. 5A-5C partially open and in locked relationship;

FIG. 8 is a sectional view on the line 8--8 of FIG. 5A;

FIG. 9 is a sectional view of another form of the embodiment shown inFIGS. 2 and 3;

FIG. 10 is a sectional view like FIG. 4C with a spring inserted betweenthe mandrel and the tubular member; and

FIG. 11 is a sectional view like FIG. 5C with a spring inserted betweenthe mandrel and the tubular member.

DESCRIPTION OF THE PREFERRED EMBODIMENTS

The present invention will be described in detail, by way of exampleonly, in connection with one type of operation in which the presentinvention is applicable and with one type of well string and bottom holewell tool assembly as it relates to drilling a well bore, shaft or othertype of access opening to a predetermined subterranean location ortarget area by a non-rotatable drill string; however, it can beappreciated that the invention may be employed in other operations withother types of well strings, such as by way of example only, a rotarydrill string or an operating string made up by lengths of tubularmembers secured together in any suitable manner. It may also be used orwith any type of device, or with other types of bottom hole assembly.Also, the components identified as comprising a down hole directionaldrilling assembly which may be used with the orienting tool form of thisinvention are by way of example only, and are not intended as alimitation.

Attention is first directed to FIG. 1 of the drawings wherein a coiltubing unit is referred to generally by the numeral 1 with coiled tubingT coiled on a drum and extending therefrom and through an Injector Headschematically represented at E, the construction and operation of whichis well known to those skilled in the art, which is employed to forcethe coiled tubing T into and retrieve the coiled tubing T from a wellbore WB in a well known manner. The Injector Head E is positioned on thewell head that is connected to the upper end 3 of the casing C whichextends into the well bore. The coiled tubing T extends downwardly intothe well bore in the earth's surface as shown in the drawings.

In FIG. 1, one arrangement and use of the present invention isschematically illustrated with one form of a bottom hole assemblyrepresented generally by the letters BHA in FIG. 1. The surfaceequipment to receive the information from the down hole instruments isshown schematically and referred to by the term Computer in FIG. 1 ofthe drawings. Such equipment is well known and understood by thoseskilled in the art of its use.

A coiled tubing connecter represented by the numeral 15 is connectedwith the lower end of the coil tubing T. The bottom hole assemblyincludes tubular mandrel 16 which is threadedly connected to theconnector 15, the tubular member 20 which telescopically receives themandrel 16, and by way of example only, non-magnetic drill collar orcollars represented at 8 threadedly secured to the tubular member 20, amule shoe sub represented at 9, threadedly connected with thenon-magnetic drill collars, a bent sub represented at 10 threadedlyconnected with the mule shoe sub, a fluid operated down hole motor orturbine 11 threadedly connected to the bent sub 10, a sub 12 threadedlyconnected to the motor and to drill bit 13.

Elements 8,9,10,11,12,13 above designated, along with the presentinvention when used as an orienting tool, generally referred to by theletters OT, which tool includes tubular mandrel 16 and tubular member20, may be referred to as the bottom hole assembly BHA and it can beappreciated that the mandrel 16 and member 20, as above stated, may beemployed with different components other than those above enumerated orin other situations. For example, where the present invention is to beemployed as a fishing tool an overshot may be connected with theorienting tool OT and manipulated by rotation and longitudinal movementto telescopically engage a fish in the well bore. In other situations,the bottom hole assembly can be changed by those skilled in the art toinclude whatever components, tools or elements that may be necessary toaccomplish the desired results for the particular purpose intended.Also, it may be used with other well string types for variousoperations.

The use and arrangement of non-magnetic drill collars, the mule shoesub, a bent member, whether it is a bent sub or a bent motor housing, orboth, a drill bit, the computer equipment at the earth's surface, theinstruments and their location and connection with the directional downhole equipment and the surface computer equipment is well known to thoseskilled in the art of directional drilling including drilling deviatedor horizontal well bores so that no detailed description is deemednecessary. Also, the instrumentation provides an indication of theinclination of the bottom hole assembly, its azimuth and the directionof the tool face. The direction of the bend of the bent sub or the benthousing is termed the tool face. This information is relayed to thecomputer at the earth's surface. By means of the foregoing equipment ofthe present invention, and with the determination of the azimuth,inclination and tool face provided by the instrumentation in the bottomhole assembly which is relayed to the earth's surface, by any suitablemeans such as electric conductor, formulas well known to those skilledin the art can be employed to determine the direction that the well borehas been been drilled and predict future direction of the well bore thatthe directional drilling assembly will take the bit unless it ischanged.

In FIGS. 2 and 3 one form of the invention when used as an orientingtool is illustrated. The non-rotatable coiled tubing T is connected atits lower end with a coiled tubing connector 15, the construction anduse of which is well known to those skilled in the art of directionaldrilling. The connector is connected to rotator 16, shown in the form ofa tubular mandrel with a bore 16b therethrough and having preferably aplurality of circumferentially spaced, longitudinally extending helicalgrooves 16a in its outer annular surface 18, four of which are shown inthe drawings, by way of example. The rotatable tubular member 20 isprovided with a longitudinal bore 20a for telescopically receiving thetubular mandrel 16 as shown in the drawings. Keys or projections 22 onthe tubular member 20 project into the bore 20a of the tubular member tobe received in the grooves 16a of the rotator 16 and when relativelongitudinal movement occurs between the rotator or mandrel 16 and themember 20, rotation of the member 20 relative to the mandrel rotator 16occurs.

The grooves 16a in the mandrel or rotator are of any suitable lead toaccomplish whatever down hole function and result the device used withthe orienting tool is intended to accomplish. In the example herein ofdrilling a deviated or horizontal well bore it is generally desirablethat the grooves 16a in the rotator or mandrel have a lead of sufficientlength so that at least one complete revolution of the member 20 may beeffected by the mandrel or rotator 16. Preferably, a lead is used sothat more than one revolution of the member 20 may be effected in orderthat the orienting tool may be recocked or manipulated down hole toprovide any desired orientation from one oriented position to anotherwhen desired and as will be explained hereinafter.

By way of example only, a lead of 30 inches for the grooves 16a issatisfactory which provides one and one quarter complete turns (450degrees) of the tubular member 20 when rotator 16 is fully telescopedfrom fully closed position when the members 22 are immediately adjacentor contact the upper end 16h of helical grooves 16a, as shown in FIGS. 2and 4A to fully extended position when the members 22 are immediatelyadjacent or contact the lower end of grooves 16a, or the reverse wheremandrel 16 is initially fully extended out of member 20 and moved tofully closed position. This enables the mandrel or rotator 16 to effectmore than one complete revolution of the tubular member 20 duringorienting or rotation of the bottom hole assembly to accomplish thedesired manipulation for orienting the bottom hole assembly to guide ordirect the drilling of the well bore in the desired direction or manner.

By way of example only, assume that 360 degrees of rotation was requiredto attain an oriented position of North and that the mandrel of theorienting tool has been lowered into the member 20 to accomplish suchoriented position. Assume that a new oriented position of South isrequired. Since South is 180 degrees from North, the member 20 cannot berotated far enough by further lowering of the mandrel 16 into the member20 to attain the desired orientation. It is therefore necessary torecock or open the orienting tool by removing some of the coil tubingfrom the well bore by means of the Injector Head at the earth's surfacewhich will pull mandrel 16 up to extend it relative to member 20. Whenmandrel 16 is fully extended out of member 20, the orienting tool willbe back at approximately North with 450 degrees again available fororientation purposes and a direction of South can now be accomplished bycollapsing or lowering mandrel 16 into the member 20. This isaccomplished by lowering the coil tubing by means of the Injector headwhich pushes, or collapses mandrel 16 into the member 20 until thedesired new oriented position of South is attained.

After the rotatable tubular member 20 has been rotated by raising orlowering the coiled tubing to accomplish the desired orientation throughrotation of member 20, the lock generally referred to by the numeral 25is then actuated, as will be described hereinafter,to lock the mandrelor rotator 16 and the tubular member 20 together to maintain the bottomhole assembly including the drill bit, down hole motor and bent sub inthe desired orientation or position during subsequent drillingoperations.

The tubular mandrel or rotator 16 includes an extension 16c having abore connected with the bore 16b to form a continuation of the bore 16b.In the FIGS. 2 and 3 form the extension is of smaller diameter with asmaller diameter bore than the portion of mandrel or rotator 16 in whichit is connected. The lower end of the tubular mandrel portion 16c isprovided with a centralizer 16d for maintaining alignment of the rotator16 within the tubular member 20 during relative longitudinal movementbetween the mandrel 16 and member 20 in operation.

The location of the target area, in the example herein a subterraneantarget area to which a well bore is to be drilled, is provided to theoperators at the earth's surface manning the computer equipment andthose operating the drilling equipment and operations. From theinstrumentation readings provided by the instruments in the bottom holeassembly which readings are relayed to the earth's surface by suitablemeans such as electrical cable (not shown) in the bore of the coiledtubing, the operators at the earth's surface can calculate and prescribeby formulas well known in their art how the bottom hole assemblyincluding the bent sub, down hole motor and drill bit must be orientedor positioned to drill the well bore to hit the target area. If thebottom hole assembly including the drill bit and down hole motor requireorienting from one position to another to face in a different direction,the lock 25 is released and the mandrel 16 and member 20 released fromthe slip segments. Then the coiled tubing is manipulated (pushed orpulled) to move the rotator or mandrel 16 longitudinally relative to thetubular member 20 and since the weight of the down hole assembly willnormally maintain it in position, the mandrel will move in or out of themember 20 in response to longitudinal movement of the coil tubing toimpart or provide the desired rotation of the down hole assembly andhence the desired orientation of the bent sub, down hole motor and drillbit. In some cases slight relative longitudinal movement of only afraction of an inch is all that is required between the mandrel 16 andmember 20.

With the mandrel 16 and tubular member 20 in unlocked relation, as shownin FIG. 1, raising or lowering of the coiled tubing T by the InjectorHead E extends or telescopes, respectively, the mandrel or rotator 16relative to the rotatable member 20 which rotates member 20 relative tothe non-rotatable rotator or mandrel 16 and to the coiled tubing Tconnected to mandrel 16. This rotation changes the orientation of thebent sub, motor and drill bit to that dictated by the amount ascalculated by the steering operator at the earth's surface from the theinformation relayed to the earth's surface by the instrumentationassociated with the down hole assembly as being necessary to properlyorient the bent sub, down hole motor and drill bit to drill the wellbore into the target area.

It is then necessary to actuate the lock, referred to generally at 25 toreleasably lock the mandrel 16 and tubular member 20 in their orientedrelation to maintain the orientation during the subsequent drillingoperation. The lock 25 includes piston means referred to generally at 24which piston means has slip means referred to generally at 21 integrallyformed thereon or secured thereon. Piston means 24 includes piston 26having seals 27 and 27a for sealing between the piston and the innersurface of bore 20a and between the piston and the extension 16c,respectively, and in the form shown they are on the piston 26. A firstshoulder 23 formed on the member 20 projects into the bore 20a as shownin FIG. 2 and this shoulder supports piston 26. An opening 23a extendslongitudinally through the portion of the member 20 on which shoulder 23is formed and the extension 16c extends there through and through anopening in the piston 26 as shown in the FIG. 2 form. The slip means 21includes arms 28 extending from piston 26 with slip segments 29 on thearms 28. A second shoulder 30 in bore 20a is spaced longitudinally fromfirst shoulder 23 and an opening 30a is provided in the second shoulder,as shown, for receiving extension 16c therethrough. An annular taperedsurface portion 30b is formed in the opening 30a adjacent the secondshoulder 30 for receiving the slip segments 29 as will be described. Aspring 31 extends between the first shoulder 23 and the piston 26 tonormally maintain slip means 21 in spaced relation to surface portion 34and unlocked to assist in maintaining the mandrel 16 and the member 20from prematurely engaging.

Increasing fluid pressure and volume in the coiled tubing causes it toact through the opening 34 in the centralizer 16d on extension 16c andthrough the opening 23a in first shoulder 23 to move piston 26 upwardlyand collapse the spring 31 so that one side surface 31a of the arcuateslip segments 29 engages the annular tapered surface 30b on member 20and another side surface 32 of the slip segments engage the outersurface of the extension 16c of the mandrel, as best illustrated in FIG.3. This locks the mandrel 16 and rotatable member 20 in their relativelyrotated, or oriented position during drilling operations. Drillingoperations may then be initiated by supplying sufficient fluid pressureand volume through the coiled tubing, the mandrel 16, member 20 and thebalance of the bottom hole assembly to impart rotation to the down holemotor 11 and the drill bit 13 in a manner well known to those skilled inthe art to drill the well bore.

Drilling operations may be interrupted periodically such as, by way ofexample only, every 30 feet, and instrument readings taken and relayedto the earth's surface for calculation to see if further orientation ofthe bent sub, down hole motor and drill bit is required to assure thatthe target area will be hit by the well bore being drilled by the drillbit.

Since mandrel 16 member 20 are locked together when in a desiredoriented position as illustrated in FIG. 3, lock 25 must be released andthe orienting tool manipulated, if necessary, as will be described toassist the spring 31 in releasing slip segments 29 from the mandrel 16and member 20. Longitudinal movement can then occur between mandrel 16and member 20 to enable the mandrel 16 to effect further rotation of themember 20 by longitudinal movement of the coil tubing and mandrel 16 toeffect rotation of the bottom hole assembly to reorient the bent sub,down hole motor and drill bit to steer the down hole motor and drill bitto drill the well bore in the direction desired.

If the present invention is near the vertical portion of the well bore,the lock 25 may be released by reducing the fluid pressure and volume,or shutting off the pumps, or compressors so that the spring force ofspring 31 overcomes the fluid pressure acting on the piston 26 to unseatthe slip segments 29 to enable the mandrel to be pulled up relative tothe bottom hole assembly. In some situations it may be necessary tolower the coiled tubing to bump, or slightly tap, the drill bit on thebottom of the well bore and then pull up on the coiled tubing to releasethe mandrel 16 and the tubular member 20 from the slip segments. Themandrel 16 and the tubular member 20 can then be recocked or opened,(extended) relative to each other either by pulling on the coil tubingby the Injector Head E to lift or extend the grooved mandrel 16 out ofthe member 20 since member 20 will tend to maintain its position byreason of its weight and the weight of the bottom hole assembly andreorientation accomplished as above described.

FIG. 9 illustrates an alternate form of the invention shown in FIGS. 2and 3. A spring S is positioned between the mandrel or rotator 16 andthe rotatable member 20 to assist in urging them apart after the lock 25is released. The spring S assists in maintaining the rotator or mandrel16 and rotatable member 20 in a longitudinal spaced relationship untilrelative longitudinal movement occurs therebetween which collapses ortelescopes them together toward a closed position that overcomes theforce in spring S. It also assists in enabling successive orientationsto be accomplished in the well bore by the present invention in themanner as described herein. As shown in FIG. 9, the spring S is betweenshoulder 70 on the rotator 16 and a shoulder 71 on tubular member 20 sothat when the rotator or mandrel 16 and the tubular member 20 aretelescoped together or moved toward a closed position the force ofspring 20 is overcome to collapse it until the desired oriented orrotated position of tubular member 20 is attained.

The assembly of the present invention is accomplished by connecting theinstruments and down hole drilling components comprising the down holeassembly together and connecting the instruments with the cableconductor in the coiled tubing and connecting the mandrel 16 and tubularmember 20 together along with the lock 25 to form the orienting tool.The mandrel 16 is connected with the connector 15 on the lower end ofthe coiled tubing and the tubular member with the adjacent component ofthe assembly, which in this example is the non-magnetic drill collars.

The coiled tubing is connected with a drilling fluid source of anysuitable type which is well known to those skilled in the art of welldrilling to circulate through the coiled tubing to perform variousfunctions such as actuating the piston means to lock the mandrel 16 andmember 20 together, circulate cuttings to the earth's surface, actuatethe down hole motor to rotate the drill bit, and any other function forwhich the fluids may be normally employed in drilling operations.

The well tool assembly is lowered into the well bore, which may be apreviously drilled well bore or a partially drilled well bore to receivethe coiled tubing and bottom hole assembly. Drilling operations areinitiated and instrument readings relayed by the cable, or other meansto the computer at the earth's surface. The bottom hole assembly isoriented and reoriented down hole as may be required to comply with theguidance system to drill to the designated or desired target area. Theorienting is accomplished by moving the coiled tubing longitudinally inor out of the well bore to move the mandrel accordingly either in or outof the tubular member 20 which rotates member 20. The grooves 16a, inthe embodiments shown, extend on the mandrel 16 in a left hand directionso that lowering of the mandrel 16 by the coil tubing T into the member20 rotates the member 20 to the right, and raising the coil tubing tomove the mandrel 16 out of the member 20, turns the member to the left.The member 20 is rotated the amount dictated by the resultinginformation derived from the instrument readings to attain the requiredorientation of the down hole assembly. The lock 25 is then actuated byincreasing pump pressure and volume to move the piston means 24 so thatthe slip means 21 overcomes the spring force of spring 31 normallymaintaining the slips retracted and then the slips engage the mandrel 16and member 20 to lock them together to maintain the desired orienteddrilling direction.

When it is desired to reorient, the lock must be first released byrelieving pump pressure or shutting off fluid pressure to relieve theforce acting on the piston. If this does not release the mandrel andmember for relative movement, the assembly is picked up off bottom andgently tapped or bumped on the well bore bottom to enable the spring toact to release the lock 25. The reorientation is then accomplished asdescribed above, the lock 25 is actuated by fluid pressure to engagemandrel 16 and member 20 and drilling operations continued.

Attention is next directed to FIGS. 4A, 4B and 4C wherein like numeralsrepresent like components to that described with regard to FIGS. 2 and3.

FIGS. 4A-4C represent another form of the invention and illustrate suchform in closed and unlocked position. Seal means 40 are provided betweenmandrel 16 and tubular member 20 to inhibit the entry of debris or wellfluid between mandrel 16 and member 20. Lock means 25 includes piston 26on mandrel 16 which piston is sealably engaged in the bore of member 20by seals 27 as shown in FIG. 4C.

The piston means 24 in this embodiment also includes slip means 21 sincetubular piston extension 35 is connected to piston 26 in any suitablemanner as shown in FIG. 4C. The extension 35 extends within the tubularmember 20 and surrounds the reduced outer diameter extension 16c of therotator or tubular mandrel 16 to abut and support the slip means 21 inlongitudinally spaced relationship relative to the piston 24 as shown inFIGS. 4B, 4C. This arrangement enables the slip segments 29 to engage aportion on the extension 16c of the mandrel spaced from the portion ofthe mandrel engaged by the seals 27a as better seen in FIG. 4C.

The slip means 21 includes an annular base 21a from which extend theslip arms 28 with annular slip segments 29 thereon. The slip segments 29are provided with an annular tapered surface 31a on one side forengaging the annular tapered counterbore 30b adjacent the shoulder 30surrounding the opening 30a formed in the member 20, and another sidesurface 32, which surface 32 is serrated as shown to provide a bettergrip for engaging with the annular surface on the reduced extension 16cof the rotator mandrel 16. The spring 31 extends between the shoulder 45on the base 21a and the shoulder 30 on the member 20.

Assembly and operation including orientation and reorientation of thebottom hole assembly including the bent sub, down hole motor and drillbit is accomplished as described with regard to the FIGS. 2 and 3embodiment. Longitudinal movement of the coil tubing T moves the mandrel16 and this rotates the member 20 to accomplish the desired orientationas dictated by the steering operator at the earth's surface, in a manneras described with regard to the FIGS. 2 and 3 embodiment.

After the orientation has been accomplished, the lock means 25 may beactuated to lock mandrel and member 20 in their oriented or relativelyrotated relationship. When fluid pressure in coil tubing T is increasedsufficiently to overcome the spring force of the spring 30, the piston26 is moved upwardly by fluid pressure and volume from the coil tubingacting on the lower end of the piston 26 as represented by the arrow 36between the member 20 and reduced diameter extension 16c as shown inFIG. 4C so that the annular tapered surface 31a on one surface side ofslip annular or arcuate slip segments 29 engages tapered annular surface30b in opening 30a of member 20 and the other surface 32 on the otherside of slip segments 29, which surface is serrated, engages the outersurface of extension 16c of mandrel 16. This locks the mandrel 16 andmember 20 together to prevent relative longitudinal movementtherebetween and maintains the orientation of the down hole assemblyincluding bent sub, down hole motor and drill bit. Fluid pressure andvolume in the coiled tubing is then increased, or maintained at apressure desired to operate the down hole motor which rotates the drillbit to drill the well bore in the direction dictated by the orientationprovided by the steering system.

The grooved mandrel 16 and member 20 remain locked by the lock means 25until the target area is drilled into or until it is desirable todisengage them for repositioning them relative to each other to rotatefor orienting the downhole motor, bent sub and drill bit face in anadjusted position to assure that the well bore is drilled to penetratethe target area as desired. To accomplish repositioning, the lock meansis released by reducing the fluid pressure that is conducted through thecoiled tubing and into the bottom hole assembly and out the down holemotor to rotate it and the bit. When the fluid pressure is reduced belowthe spring force on spring 30, the coiled tubing and down hole assemblywith the drill bit on the lower end thereof may, if necessary, belowered by the Injector Head E to bump or tap the drill bit on thebottom of the well bore just enough to jar the outer tubular member 20relative to the grooved mandrel 16 so that the spring 30 may act todislodge the slip segments 29 from engagement with the annular taperedsurfaces on the tubular member and from engagement with the portion 16bof the grooved mandrel to accommodate longitudinal movement of the slipsto return them to the released position shown in FIG. 4B.

FIG. 10 illustrates an alternate form of the invention shown in FIGS.4A-4C inclusive . It is the same except in FIG. 4B the spring S has beenadded as shown in FIG. 10 and is positioned between the shoulder 70 onmandrel or rotator 16 and the shoulder 71 on rotatable member 20 toassist in urging them apart after the lock 25 is released. The remainderof this embodiment is that as shown in FIGS. 4A and 4C. and theoperation is similar to that as described with regard to the FIGS. 2 and3 form of the invention with the spring functioning as described withregard to FIGS. 2 and 3. The spring S assists in maintaining the rotatoror mandrel 16 and rotatable member 20 in a longitudinal spacedrelationship until relative longitudinal movement therebetween occurs toovercome the force in spring S to collapse it as they telescope togethertoward a closed position until the desired oriented or rotated positionof tubular member 20 is attained. It also assists in enabling successiveorientations to be effected in the well bore as described herein.

Attention is now directed to the embodiment illustrated in FIGS. 5through 7A, inclusive wherein like numerals are applied to likecomponents described with regard to the embodiments of FIGS. 2 through4C inclusive.

The assembly, operation and function of this embodiment is generallysimilar to that described with regard to the FIGS. 2-4C embodiments, andin this embodiment the engagement of the slips between the tubularmember and the mandrel is modified; locking of the member 20 and mandrel16 is prevented when they are fully collapsed together; and a secondpiston 60 on the mandrel 16 assists in locking tubular member 20 andtubular mandrel 16 together; and after the lock 25 between mandrel 16and member 20 is released to accommodate relative movement betweenmandrel 16 and member 20, the piston 60 on the mandrel enables themandrel 20 and member to be pumped apart, or recocked as will bedescribed hereinafter.

The mandrel 16 is provided with circumferentially spaced, longitudinallyextending grooves 16a in which keys or members 22 on tubular member 20engage. Seals 40 sealably engage between the mandrel 16 and member 20 asshown in FIG. 5A to prevent the entry of foreign substances into theorienting tool. The extension 16d of the mandrel 16 has a portion 16ewhich is reduced in outer diameter in relation to the diameter of theextension 16d as shown in FIGS. 5B, 6B and 7A.

In this form, the piston means 24 includes first piston 26, a pistonextension 35 and slip means 21 which provide the lock means 25. A secondpiston 60 is on the mandrel 16.

When the mandrel 16 and member 20 are fully collapsed as shown in FIGS.5A-5C, the lower end of piston 26 abuts the projection 41 secured tomember 20 which extends into the bore 20a as seen in FIG. 5B. Thisprevents any further movement of the piston means including piston 26,extension 35 and slip segments 29 of slip means 21 to prevent engagementof the slip segments with the tapered, annular surface 16f on themandrel and with the inner wall defining bore 20a of member 20, so thatthe lock 25 is deactivated and cannot secure the mandrel 16 and member20 together when they are fully collapsed together. Should member 20 andmandrel 16 be locked together by the lock 25 when they are fullycollapsed, it would be difficult, if not impossible to release them in awell bore so that further orientation could be effected, if necessary.

The first piston 26 abuts and is supported on one end of the extension35. A port 42 is in mandrel 16 adjacent the first piston 26, and aspacer 43 which may be considered a part of the mandrel or a part of thepiston 26 spaces the first piston 26 relative to the shoulder 44 on themandrel as shown. Sufficient fluid pressure from the mandrel flowsthrough port 42 and acts on piston 26 to force it and extension 35downwardly against the base 21a of the slip means 21. When the fluidpressure and volume acting on the piston 26 overcomes the spring forcein spring 31, the spring collapses and permits the arcuate, taperedsurface 31a on one side of the slip segments 29 to engage the taperedsurface 16f on the mandrel and permits the other surface 32 on the otherside of slip segments 29 to engage the inner wall of the member 20 tolock the mandrel 16 and tubular member 20 together after the member 20has been rotated relative to the mandrel to orient the down holedirectional equipment including the bent sub motor and drill bit,forming the bottom hole assembly, as desired.

After the mandrel 16 and member 20 are locked together with the slipsegments 29 the fluid pressure and volume is maintained as required fordrilling operations. This increased pressure acts between the lower endof second piston 60 and the adjacent spaced shoulder surface 71 in themember 20 to increase the locking effect or force of the slip segmentswith the mandrel 16 and the member 20 since the member acts to try tomove down in response to the fluid pressure and volume. This urges theslip segments into tighter engagement with the mandrel 16 and member 20.

When it is desired to release the lock, the fluid pressure and volume inthe coil tubing T and the mandrel 16 is reduced below the spring forceof spring 31. The spring 31 is supported between shoulders 45 and 46 onthe base of the slip means and on the mandrel, respectively, which tendsto urge the slips away from the surface 16f on the mandrel.

As shown in FIG. 5B, the stop 41 prevents the lock 25 from actuatingwhen the mandrel is fully collapsed into the member 20 so that theorienting tool remains operative to reorient when necessary ordesirable.

Due to the friction when the orienting tool OT is on its side in adeviated well bore including a horizontal well bore, it may bedifficult, if not impossible even after both the mandrel 16 and member20 are released from the slip segments 29 of the lock 25 to manipulatethe mandrel 16 and member 20 for relative movement to recock theorienting tool.

FIG. 11 shows an alternate form of the FIGS. 5-7B embodiment. It is thesame except FIG. 11 shows FIG. 5C with a spring S between the mandrel 16and tubular member 20. It assists in moving mandrel 16 and tubularmember 20 apart after the lock 25 has been released, as described withregard to the FIGS. 2-4C embodiments. More specifically, the spring S isshown between the shouilder 70 on mandrel 16 and the shoulder 71 on thesub which is connected with and may be considered as part of the member20.

In some situations, such as where lost circulation of the drilling fluidoccurs in the well bore, it may be difficult if not impossible to pumpthe mandrel 16 and the member 20 apart. The spring 20 assists in movingthem apart for another orientation as described with regard to allmodifications.

In the FIGS. 5-7A embodiment, increased fluid pressure and volume willact between the end of second piston 60 and member 20 to pump theorienting tool OT to the recocked open, or extended position. Thisenables the present invention to be employed to reorient as previouslydescribed.

The larger diameter of the inner surface of the tubular member 20enables the serrated surface of the larger arcuate slip segments 29 inthe FIGS. 5-7A form to exert a better gripping engagement with thetubular member 20.

In FIGS. 4A and 5A a plug is provided for a lubricant opening throughwhich lubricant may be provided between the spaced seals 40 and 40A.

The mandrel 16 and the member 20 of the embodiments shown may each beformed of tubular sections with suitable seals as shown for providingfluid integrity. Also suitable equalizing ports may be provided such asillustrated at 50 to equalize pressure between the assembly and the wellbore.

Those skilled in the art of drilling well bores know from experience thefluid pressure and volume required to properly operate the well tool toaccomplish its functions including the drilling operations describedherein and when it is used in other well tool forms.

In the form of the invention described herein, the keys are on thetubular member and the grooves are on the tubular mandrel and it may bedesirable in some situations to reverse their positions. As noted,orientation may be effected by telescopically collapsing the mandrel andthe tubular member toward closed position or by telescopically extendingor moving them apart.

The foregoing disclosure and description of the invention areillustrative and explanatory thereof, and various changes inarrangement, size, shape and materials as well as in the details of theillustrated construction may be made without departing from the spiritof the invention.

What is claimed is:
 1. A well tool operable by a non rotatable,longitudinally movable well string extending into a well bore forrotating a down hole device, said well tool comprising:a rotator forconnection with the non rotatable well string to move longitudinally inthe well bore in response to longitudinal movement of the non rotatablewell string; a rotatable member for telescopically receiving saidrotator; cooperating means on said rotator and said rotatable member forimparting rotation to said rotatable member and the down hole deviceupon longitudinal movement of the non rotatable well string and saidrotator to telescope said rotator into said rotatable member: and areleasable lock to lock said rotator, said non rotatable well string andsaid rotatable member in a telescoped position to lock the device in arotated position.
 2. The well tool of claim 1 wherein the non rotatablewell string is coiled tubing.
 3. The well tool of claim 1 wherein:saidrotator is a tubular mandrel with a bore therethrough; said rotatablemember is a tubular member having a bore therethrough to telescopicallyreceive said tubular mandrel; and wherein said cooperating meanscomprises:longitudinally extending helical groove means on said tubularmandrel; key means on said tubular member for engaging with said tubularmandrel groove means to impart rotation to said rotatable means uponlongitudinal movement of the non rotatable well string and said rotatorrelative to said rotatable member.
 4. The well tool of claim 1wherein:said rotator is a tubular mandrel with a bore therethrough; saidrotatable member is a tubular member having a bore therethrough forreceiving said tubular mandrel; key means on said tubular mandrel;longitudinally extending helical groove means on said tubular member forengaging with said tubular mandrel key means to impart rotation to saidrotatable member upon relative longitudinal movement between saidrotator and said rotatable member.
 5. The well tool of claim 1 whereinsaid releasable lock includes movable piston means and slip meansmovable by said movable piston means to engage and lock said rotatablemember and said rotator connected with the well string together andwherein said rotatable member has an inner surface including an annulartapered portion and wherein said rotator has an outer surface.
 6. Thewell tool of claim 1 including a centralizer on said rotator formaintaining alignment between said rotator and said rotatable memberduring relative longitudinal movement.
 7. The well tool of claim 5wherein said slid means is on said piston means.
 8. The well tool ofclaim 7 wherein said rotatable member includes a first and a secondshoulder and wherein:said piston means is supported on said firstshoulder; and spring means abutting between said piston means and saidsecond shoulder to normally maintain said slip means retracted fromlocking engagement with said rotator and said rotatable member.
 9. Thewell tool of claim 5 wherein said slip means includes annular slipsegments and said slip means is integral with said piston means.
 10. Thewell tool of claim 5 wherein said slip means includes annular slipsegments and said slip means is supported by said rotator.
 11. The welltool of claim 5 wherein said movable piston means sealably engages withthe inner surface of said tubular member and with the outer surface ofsaid tubular mandrel.
 12. The well tool of claim 5 wherein said slipmeans includes annular slip segments with annular tapered surface meanson one side and another surface on the the other side of said slipsegments for engaging with the annular tapered surface means on saidrotatable member and with the outer surface of said rotator.
 13. Thewell tool of claim 5 wherein said slip means includes annular slipsegments with annular tapered surface means on one side and anothersurface on the other side for engaging, respectively, with an annulartapered surface on said rotator and with the inner surface of saidrotatable member.
 14. The well tool of claim 13 wherein said annularslip segment surfaces which engage the outer surface of said rotator areserrated.
 15. The well tool of claim 5 including a shoulder on saidrotator and a spring abutting between said shoulder and said slip means.16. The well tool of claim 5 wherein;said piston means includes apiston; a tubular extension for supporting said piston through whichextension said rotator extends; said slip means include a base; sliparms extending from said base; slip segments on said arms; and springmeans to normally maintain said slip means disengaged from lockingengagement with said rotator and rotatable member.
 17. The well tool ofclaim 16 wherein said spring means abuts between said slip means baseand rotatable member to normally maintain said slip means disengagedfrom locking engagement with said rotator and rotatable member.
 18. Thewell tool of claim 16 wherein said spring means abuts between said slipmeans base and rotator to normally maintain said slip means disengagedfrom locking engagement with said rotator and rotatable member.
 19. Theapparatus of claim 1 wherein said rotator has a piston secured thereonsealably engaging with said rotatable member.
 20. The apparatus of claim2 wherein said rotator has a piston secured thereon sealably engagingwith said rotatable member.
 21. The apparatus of claim 3 wherein saidrotator has a piston secured thereon sealably engaging with saidrotatable member.
 22. The apparatus of claim 1 including a springbetween said rotatable member and rotator.
 23. The apparatus of claim 2including a spring for urging said rotatable member and rotator apartwhen they are not locked together by said releasable lock.
 24. Theapparatus of claim 3 including a spring between said rotatable memberand said tubular mandrel.
 25. The apparatus of claim 4 including aspring for urging said rotatable member and said rotator apart when theyare not locked together by said releasable lock.
 26. The apparatus ofclaim 5 including a spring for urging said rotatable member and saidrotator apart when they are not locked together by said releasable lock.27. The apparatus of claim 6 including a spring between said rotatablemember and said tubular mandrel.
 28. The apparatus of claim 7 includinga spring for urging said rotatable member and said rotator apart whenthey are not locked together by said releasable lock.
 29. The apparatusof claim 8 including a spring for urging said rotatable member and saidrotator apart when they are not locked together by said releasable lock.30. The apparatus of claim 9 including a spring for urging saidrotatable member and said rotator apart when they are not lockedtogether by said releasable lock.
 31. The apparatus of claim 10including a spring for urging said rotatable member and said rotatorapart when they are not locked together by said releasable lock.
 32. Theapparatus of claim 11 including a spring for urging said rotatablemember and said rotator apart when they are not locked together by saidreleasable lock.
 33. The apparatus of claim 12 including a springbetween said rotatable member and said tubular mandrel.
 34. Theapparatus of claim 13 including a spring between said rotatable memberand said rotator.
 35. The apparatus of claim 14 including a springbetween said rotatable member and said rotator.
 36. The apparatus ofclaim 15 including a spring between said rotatable member and saidrotator.
 37. The apparatus of claim 16 including a spring between saidrotatable member and said rotator.
 38. The apparatus of claim 17including a spring between said rotatable member and said rotator. 39.The apparatus of claim 18 including a spring between said rotatablemember and said rotator.
 40. The apparatus of claim 19 including aspring for urging said rotatable member and said rotator apart.
 41. Theapparatus of claim 20 including a spring for urging said rotatablemember and said rotator apart.
 42. The apparatus of claim 21 including aspring for urging said rotatable member and said tubular mandrel apart.43. The orienting tool of claim 23 including a spring for urging saidfirst member and said second member apart.
 44. Apparatus for guiding anddrilling a well bore to a desired target area with a non rotatable,longitudinally movable drill string comprising:directional drillingequipment including a drilling member to guide the drilling member todrill the well bore; instruments associated with said directionaldrilling equipment to determine the azimuth, inclination and directionof the tool face of said directional drilling equipment; surface meansto receive the instrument determinations of azimuth, inclination andtool face; relay means to conduct said instrument determinations to theearth's surface; and an orienting well tool connected with the nonrotatable, longitudinally movable drill string and with said directionaldrilling equipment, including the drilling member to orient saiddirectional drilling equipment including the drilling member to apredetermined position upon longitudinal movement of the non rotatable,longitudinally movable drill string to position the drilling member todrill the well bore to the desired target area.
 45. The apparatus ofclaim 44 wherein said orienting well tool includes:a tubular mandrelconnected with the non-rotatable, longitudinally movable drill stringand depending therefrom; a rotatable member for telescopically receivingsaid tubular mandrel; and cooperating means associated with saidrotatable member and with said tubular mandrel for imparting rotation tothe rotatable member upon longitudinal movement of the longitudinallymovable drill string arid said tubular mandrel relative to saidrotatable member to position the drilling member for drilling to thedesired target area.
 46. The apparatus of claim 45 including stop meansto limit the telescoping relation of said rotatable member and saidtubular mandrel and wherein the cooperating means accommodate not lessthan 360 degrees of rotation of said rotatable member relative to saidmandrel.
 47. The apparatus of claim 44 wherein said orienting well toolincludes:a tubular mandrel connected with the non-rotatable,longitudinally movable drill string and depends therefrom; a rotatablemember telescopically receiving said tubular mandrel; and cooperatingmeans on said tubular mandrel and said rotatable member to rotate saidrotatable member upon longitudinal movement of the non rotatable wellstring.
 48. The apparatus of claim 45 wherein said orienting toolincludes a spring between said rotatable member and said tubularmandrel.
 49. The apparatus of claim 47 including a spring between saidrotatable member and said tubular mandrel.
 50. In an orienting tool forconnection between a well string and a device to orient the device bylongitudinal movement of the well string to a predetermined position ina well bore, the invention comprising:a first member for connection withthe well string; a second member for connection with the device andtelescopically receiving said first member; a releasable lock to locksaid first member and said second member together in the predeterminedposition; and a spring between said first member and said second memberto inhibit premature actuation of said lock means.
 51. The orientingtool of claim 50 including cooperating means on said first member and onsaid second member responsive to longitudinal movement of the wellstring and said first member to orient the device in the well bore tothe predetermined position.
 52. The orienting tool of claim 51 whereinsaid cooperating means comprises helical groove means on one of saidmember and keys on the other of said members to engage the helicalgrooves means on said one member.
 53. The apparatus of claim 50 whereinone of said members has a piston secured thereon sealably engaging withthe other of said members.
 54. The orienting tool of claim 50 includinga spring for urging said first member and said second member apart whenthey are not locked together by said releasable lock.
 55. The orientingtool of claim 51 including a spring for urging said one and othermembers apart when they are not locked together by said releasable lock.56. The orienting tool of claim 52 including a spring for urging saidfirst member and said second member apart when they are not lockedtogether by said releasable lock.
 57. In a rotatable tool for connectionbetween a coiled tubing well string and a device to be oriented in awell bore the invention including:first and second memberstelescopically engageable, with one of said members engageable with thecoiled tubing well string and the other member engageable with thedevice to be oriented in the well bore; cooperating means on said firstand second members to effect rotation of said member connected with thedevice to be oriented upon longitudinal movement of the coiled tubingwell string and the member connected therewith to position the device ina predetermined rotated position; and lock means to lock said first andsecond members together in the predetermined rotated position.
 58. Theorienting tool of claim 57 wherein said lock means includes piston meansand slip means movable by said piston means to lock with said first andsecond members to retain them in the rotated position.
 59. The orientingtool of claim 57 including piston means on one of said members which isresponsive to fluid pressure to move said first and second members apartwhen substantially fully telescoped together.
 60. The orienting tool ofclaim 57 including limit means to stop the telescoping together of saidfirst and second members when said first and second members aresubstantially fully telescoped together to prevent actuation of saidlock means.
 61. The rotatable tool of claim 57 including a spring forurging said first member and said second member apart when said firstmember and said second members are not locked together by said lockmeans.
 62. A releasable lock for a down hole well tool for rotating adevice in a well bore, which tool has a first non rotatable member forconnection with a non-rotatable well string and a second rotatablemember for connection with the device to be rotated including:a piston;seal means for sealably engaging said piston between the first andsecond members; and slip means associated with said piston means movablein response to movement of said piston means to secure the first andsecond members together.
 63. A method of assembling apparatus fordrilling a well bore with a non rotatable longitudinally movable, drillstring wherein the apparatus includes down hole directional drillingequipment including a drilling member forming a bottom hole assembly,instruments for determining the azimuth, inclination and direction ofthe tool face of the bottom hole assembly, surface equipment forreceiving the instrument determinations, relay means for relaying theinstrument determinations to the surface equipment and a down hole welltool having a non rotatable member telescopically engageable with arotatable member, the well tool operable by moving the nonrotatablelongitudinally movable drill string to rotate the down hole directionaldrilling equipment including a drilling member and to lock the nonrotatable member and the rotatable member together to guide drilling thewell bore to a target area comprising the steps of:connecting therotatable member of the well tool with the down hole directionaldrilling equipment including a drilling member; and connecting the nonrotatable member of the well tool with the non-rotatable longitudinallymovable drill string.
 64. A method of orienting a bottom hole assemblyin a well bore with a non-rotatable drill string to drill a well bore toa desired target area wherein the bottom hole assembly includesdirectional drilling equipment including a fluid actuated motor and adrilling member operable thereby to drill the well bore to drill a wellbore to a desired target area instruments for determining the azimuth,inclination and direction of the tool face of the bottom hole assembly,surface equipment for receiving the instrument determinations, relaymeans for relaying the instrument determinations to the surfaceequipment, a down hole orienting well tool having first and secondmembers telescopically engageable, with one of said members engageablewith the non rotatable, longitudinally movable well string and the othermember engageable with the bottom hole assembly to be oriented in thewell bore and cooperating means on the first and second members toeffect rotation of the member connected with the bottom hole assembly tobe oriented and a lock normally retained by a spring in unlockedrelation to the first and second members but responsive to fluidpressure in the orienting well tool to lock the first and second memberstogether in a predetermined oriented position comprising the stepsof:lowering the drill string with the well tool and bottom hole assemblyincluding the directional drilling equipment including a fluid actuatedmotor and drilling member actuated thereby into the well bore; relayingto the surface equipment information from the instruments; manipulatingthe drill string longitudinally and the member connected therewithlongitudinally to rotate the member connected with the bottom holeassembly directional drilling equipment including a fluid actuated motorand drilling member actuated thereby relative to the member connected tothe drill string to orient the bottom hole assembly to position thedirectional drilling equipment including a fluid actuated motor anddrilling member actuated thereby to drill the well bore to the targetarea; supplying fluid pressure to the motor to actuate the drillingmember to drill the well bore; and moving the non rotatable,longitudinally movable drill string in the well bore.
 65. The method ofclaim 64 including the steps of increasing the fluid pressure in the nonrotatable, longitudinally movable well string and orienting well tool toovercome the spring so that the lock secures the first and secondmembers together.
 66. The method of claim 65 including the step ofreleasing the lock by decreasing the fluid pressure in the nonrotatable, longitudinally movable well string and orienting well tool toenable the spring to disengage the lock from the first and secondmembers.
 67. The method of claim 66 including the step of bumping thedrill member on the bottom of the well bore to assist in releasing thelock means.
 68. The method claim 66 including the step of manipulatingthe non-rotatable, longitudinally movable drill string and the memberconnected therewith to move the member connected with the drill stringoutwardly of the member connected with the bottom hole assembly.
 69. Themethod of claim 68 including the step of lowering the member connectedwith the longitudinally movable drill string to move it into the memberconnected with the bottom hole assembly to reorient the bottom holeassembly to another oriented position.
 70. The method claim 67 includingthe step of manipulating the non-rotatable, longitudinally movable drillstring and the member connected therewith to move the member connectedwith the drill string outwardly of the member connected with the bottomhole assembly.
 71. The method of claim 70 including the step of loweringthe member connected with the drill string to move it into the memberconnected with the bottom hole assembly to reorient the bottom holeassembly to another desired position.
 72. The method of claim 65 whereinseal means are provided between the first and second members, andincluding the step of providing fluid pressure to pump the memberconnected to the drill string outwardly relative to the member connectedto the drilling member.
 73. The method claim of 72 including the step ofraising the non-rotatable, longitudinally movable drill string and themember connected therewith to move the member connected with the drillstring outwardly of the member connected with the directional drillingequipment, including a fluid actuated motor and drilling member actuatedthereby.
 74. The method of claim 72 including the step of lowering thenon rotatable, longitudinally movable drill string and the memberconnected therewith to move it into the member connected with the bottomhole assembly to rotate the bottom hole assembly.
 75. A method oforienting a device to at least one position in a well bore by a wellstring which is connected to one member of a down hole orienting toolwith the device connected to to at least one other member of the downhole orienting tool, the members including cooperating means operable bymanipulation of the well string to rotate the member connected to thedevice relative to the well string and a releasable, fluid actuated lockto lock the members in the position to which the device is oriented,comprising the steps of:lowering the well string with the members andthe device into the well bore; lowering the well string with the onemember connected therewith to rotate the device connected with the othermember to a predetermined oriented position; and locking the memberstogether in the oriented position.
 76. The method of claim 75 includingthe steps of:unlocking the lock and manipulating the well string torotate and lock the members and device in another oriented position.